bp full year 2006 results and strategy update · 2007-02-06 · 2006: financial results •...

BP Full Year 2006 Results and Strategy Update6 February 2007

John Browne

Group Chief Executive

Cautionary StatementForward Looking Statements Cautionary StatementThis presentation and the associated slides and discussion contain forward looking statements, particularly those regarding capital expenditure, capital investments, spending on integrity management, annual charges, cost inflation, production and impact of delays in projects on production, expected return to capacity of projects, share buybacks and other distributions to shareholders, group costs, divestment proceeds and their use, effective tax rate, future

performance, gearing, growth opportunities, global economic growth, global oil demand growth, oil and gas prices, performance, oil and gas production, production growth, refining

margins, refining availability and capacity, outlook for refining environment, the timing of major projects and their contribution to BP net resources and the application of technology. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that will or may occur in the future. Actual results may differ from those expressed in such statements, depending on a variety of factors, including the timing of bringing new fields on stream; future levels of industry product supply; demand and pricing; operational problems; general economic conditions; political stability and economic growth in relevant areas of the world; changes in laws and governmental regulations; exchange rate fluctuations; development and use of new technology; changes in public expectations and other changes in business conditions; the actions of competitors; natural disasters and adverse weather conditions; wars and acts of terrorism or sabotage; and other factors discussed elsewhere in this

presentation.

Reconciliations to GAAP -

This presentation also contains financial information which is not presented in accordance with generally accepted accounting principles (GAAP). A quantitative reconciliation of this information to the most directly comparable financial measure calculated and presented in accordance with GAAP can be found on our website at www.bp.com

Cautionary Note to US Investors

-

The United States Securities and Exchange Commission permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or formation tests to be economically and legally producible under existing economic and operating conditions. We use certain terms in this presentation, such as “resources”

and “non-proved reserves”, that the SEC’s guidelines strictly prohibit us from including in our filings with the SEC. U.S. investors are urged to consider closely the disclosures in our Form 20-F/A, SEC File No. 1-06262, available from us at 1 St James’s Square, London SW1Y 4PD. You can also obtain this form from the SEC by calling 1-800-SEC-0330.

February 2007

John Browne


Agenda

•

Review of 2006

•

Strategy and performance in context

•

Trading environment

•

2007 priorities

-

Business updates

•

Financial framework

•

2007 guidance

•

Q&A

2006: Financial results

•

Replacement cost profit-

$22.3bn, up 15%

-

Per share 111.1¢, up 22%

•

Post tax operating cash flow $28.2bn, up 5%

•

Quarterly dividend per share 10.325¢-

Up 5% vs. last quarter

-

Up 10% vs. last year

•

Distributed $23.2bn to shareholders: $15.5bn by share buybacks

•

Divestment proceeds of $6.3bn

•

Gearing at 20%, bottom of target range

2006: Incidents and responses

•

Texas City

-

Implementing Baker Panel’s process safety recommendations

•

Prudhoe Bay and Thunder Horse

-

Embedding learning across the company

•

Propane trading

2006: Milestones

•

2006 reserve replacement 113%

•

10 new discoveries including Kaskida, Titania, Urano

and in Uvat

area

•

New upstream access: Pakistan, India and Oman

•

Start-up of 9 new upstream projects

•

Re-commissioning of Texas City continues

•

Significant progress in Alternative Energy

•

$3bn Whiting refinery investment sanctioned

Byron Grote

Chief Financial Officer

Trading environment

010203040506070

1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q

Oil realization$/bbl

2005 2006

0

2

4

6

8

10

12

1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q

Gas realization$/mcf

2005 2006

02468

101214

1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q

Refining indicator margin$/bbl

2005 2006

Change vs. 2005

Average realizations4Q Year

Crude oil $/bbl 5% 23%

Natural gas $/mcf (30)% (4)%

Total hydrocarbon $/boe (10)% 12%

Refining indicator margin $/bbl (17)% (2)%

Financial results

Results for the fourth quarter $bn % % per share

•

Replacement cost profit 3.9 (12)% (6)%

•

Profit including inventory gains/losses 2.9 (22)% (16)%

•

Net cash provided by operating activities 5.0 17% 24%

¢/ share•

Dividend to be paid next quarter 10.325 +10 %

Results for full year $bn % % per share

•

Replacement cost profit 22.3 15% 22%

•

Profit including inventory gains/losses 22.0 (2)% 4%

•

Net cash provided by operating activities 28.2 5% 11%

Change vs. 2005

Change vs. 4Q 2005

Exploration & Production

•

Lower gas realizations

•

Lower volumes

•

Sector specific inflation

•

Greater integrity spend

•

Higher non-cash costs

•

TNK-BP -

Absence of disposal gain

-

Lagged tax reference prices

•

Non-Operating Items (NOI)-

Embedded derivatives

Pre-tax $bn

0

1

2

3

4

5

6

7

8

NOI 4Q 064Q 05 Underlying

5,240

(979) Non-operating items

7,545 Underlying result

6,566 5,063Total result

(177)

$m$m

Refining & Marketing

•

Higher Texas City volumes

•

Absence of rationalization charges

•

Smaller fair value charge

•

Higher turnaround costs and integrity spend

•

Lower refining and marketing margins

(0.3)

(0.2)

(0.1)

0.0

0.1

0.2

0.3

0.4


36550 Non-operating items

(215) Underlying result

(165) 312Total result

(53)

$m$m

Pre-tax $bn

Gas, Power & Renewables

•

Lower NGL

and marketing & trading contribution

•

Smaller fair value gain

•

Non-Operating Item (NOI)-

Disposals

0.0

0.1

0.2

0.3

0.4

0.5

0.6

0.7


255

(307) Non-operating items

436 Underlying result

129 470Total result

215

$m$m

Pre-tax $bn

Other business & corporate

•

2006 underlying charge consistent with prior guidance

(0.5)

(0.4)

(0.3)

(0.2)

(0.1)

0.0

(88)(64) Non-operating items

(345) Underlying result

(409) (276)Total result

(188)


$m$m

Pre-tax $bn

Guidance on 2007 items

•

OB&C: annual charge of $900m±$200m

•

Full year effective tax rate: 37%

•

Rules of thumb:

Full year (pre-tax)

$m

Oil price

Brent ±$1/bbl

500

Gas price

Henry Hub ±$0.1/mmbtu 90

Refining margin

GIM ±$1/bbl

950

Note:

Rules of thumb provided are approximate.

Actual impacts will depend on:

•

Volumes / portfolio mix

•

Absolute price level

•

Refining availability

Sources and uses of cash

* Acquisitions include Rosneft

IPO

Post tax $bn

2005 2006

Disposals

Operations

Buybacks

Dividends

Organic capex

Disposals

Operations

Buybacks

Dividends

Organic capex

Acquisitions*26.7 28.2

0

5

10

15

20

25

30

35

40

Sources Uses Sources Uses

Net debt ratio

20062005

%

10

15

20

25

30

35

40

1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q

Net debt ratio = net debt / (net debt + equity)

Shareholder distributions

Buybacks Dividends Share issues

2002 2003 2004 2005 2006(3)

0

3

6

9

12

15

18

21

24

$bn

John Browne


Strategy

E&P•

Focus on the most prolific hydrocarbon basins and the biggest fields

•

Build leadership positions in these areas•

Manage decline of existing producing assets and divest when appropriate

Gas•

Access to premium gas markets

R&M•

Integrated chains of supply based around complex efficient refineries

•

Marketing•

Build acetic acid and PTA capacity in Asia

Alternative Energy•

Build sustainable low carbon business

Number of countries > 100mbd

Strategic indicators

2.667.125.5Share price ($/ADR)

1.25.34.5Reserves/share (boe/ADR)

2.53715Share of gas in total production (%)

n.a.83

4.622047Market capitalisation ($bn)

1.8215120Average refinery size (mbd)

1.428182000Total refining capacity (mbd)

2.117.78.4Reserves (bn boe)

1.50.430.28Production/share (boe/ADR/yr)

2.739261428Production (mboed)

Ratio20061995

*

*

* At 31/12/06

Crude oil prices since 1995

Daily pricesSource: Platts

quotes

Dated Brent$ per bbl

12-year average$29.34

2006200520042003200220012000199919981997199619950

10

20

30

40

50

60

70

80

Oil demand and economic growth

Oil demand GDP

Source: oil demand, BP estimate; GDP, ’00 -’06 Oxford Economic Forecasting

%

0

1

2

3

4

5

00 01 02 03 04 05 06

Oil supply growth and surplus capacity

Non-OPEC output growth OPEC surplus capacity

Year-on-year change; Source: BP

End year; Source: ’00 –

’03 DOE/EIA; ’04 –

’06 BP estimates

Million b/d

Million b/d

0

2

4

6

00 01 02 03 04 05 06

0

2

4

6

00 01 02 03 04 05 06

Crude oil prices 2000 to 2007

Daily pricesSource: Platts

quotes

+19%2005 Avg$54.52

2006 Avg$65.14

20062005200420032002200120000

10

20

30

40

50

60

70

80

Dated Brent$ per bbl

US gas prices 2000 to 2007

Chart uses daily “common”

Henry Hub prices; annual averages are based on the “monthly Platts

index”Source: Platts

quotes

-16%

2005 Avg$8.64

2006 Avg$7.24

20062005200420032002200120000

2

4

6

8

10

12

14

16

18

20

US Henry Hub$ per mmbtu

Refining margins 2000 to 2007

Daily marginsBP Global Indicator Margin (GIM); 2006 portfolio basis

-1%

2005 Avg$8.50

2006 Avg$8.39

20062005200420032002200120000

5

10

15

20

25

30

$ per bbl

2007 priorities

•

Safety

-

Personal safety

-

Process safety

-

Environment

•

Performance

Safety in operations 1999 to 2006

Recordable injury frequency

Oil spills greater 1 bbl

Integrity management incidents*

Workforce fatalities

HiPO: High Potential Incident; MIA: Major Incident Announcement* Excludes Innovene

0.0

0.4

0.8

1.2

1.6

99 00 01 02 03 04 05 06

05

101520253035

99 00 01 02 03 04 05 06

Non-road related Road related

0200400600800

10001200

99 00 01 02 03 04 05 06

0

20

40

60

80

100

2004 2005 2006

HiPO MIA

Focus on process safety

•

Actions under way to improve integrity of plant and operations

-

Implementing new standards

-

Implementing new Operations Management System

•

Baker Panel recommendations accepted –

provides further learning

•

Sustaining level of integrity management spending

-

Around $1bn increase over 2006

2007 priorities

•

Safety

•

Performance

-

Deliver upstream projects

-

Atlantis by end 2007

-

Thunder Horse by end 2008

-

Texas City

-

Expected to be processing 400,000 bpd by end of 2007

Tony Hayward

Group Chief Executive Designate

Exploration & Access

Exploration•

Deepwater Gulf of Mexico −

Kaskida

•

Angola−

Titania

and Urano

•

TNK-BP−

Uvat

area

Access•

Oman

•

Pakistan•

India

•

Gulf of Mexico lease sale

Reserves replacement

Reserves replacement for subsidiaries + associates, excludes the

effects of acquisitions & divestments, SEC basis

5 year moving average

0

20

40

60

80

100

120

140

160

85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 00 01 02 03 04 05 06

%

Major projects 2006 key start ups

•

Azerbaijan−

BTC Pipeline / East Azeri

•

Algeria−

In Amenas

•

Trinidad−

Cannonball

•

Egypt−

Temsah Redevelopment

•

Angola−

Dalia

Major projects 2007 key start ups

•

Angola−

Greater Plutonio

−

Rosa−

Kizomba A Phase 2

•

Gulf of Mexico−

Atlantis

−

King Subsea

•

Trinidad−

Red Mango

•

North America Gas−

San Juan Coal Bed Methane expansion

Existing Profit Centres Alaska, North Sea, North America Gas, Latin America,

Egypt, Middle East

•

Production lower than forecast in Alaska and North Sea−

Increased levels of downtime

−

Reduced operational efficiency−

Infill drilling activity slippage -tight supply chain

•

Resource base strong -reservoirs performing as expected

•

Other EPCs

–

strong performance−

North America Gas

−

Pan American Energy−

Egypt

Bob Dudley

President and CEO TNK-BP

TNK–BP

Project areas

Core production areas

Refineries

Volga Urals

West Siberia

Moscow

East Siberia

Samotlor

Saratov Orenburg

RospanNyagan

Kovykta

VerknechonskUvat

Ukraine

Ryazan

Strategy and performance highlights

The strategy remains unchanged

Resources to Reserves to Production•

Production growth of 30% since 2003

•

Licence extensions•

New Resource Access of 5 Bn boe risked, 60% Exploration Success rate

Margin Enhancement•

$600m Ryazan

Modernization, Increased Refining throughputs > 15%

•

Retail Expansion, TNK re-branding and BP Ultimate launch•

Marketing business growth (Lubes, Bitumen)

Gas•

Associated Gas Utilization Programme

•

Foundation of major gas projects

TNK–BP production and capex 2003 –

2007

mmboedCapex $bn

Disposals

0.0

0.5

1.0

1.5

2.0

2.5

2003 2004 2005 2006 2007e0

1

2

3

4

5Capex

TNK-BP projection for 2007

Major projects and new access

Volga Urals

West Siberia

East Siberia

Orenburg

Rospan

Kovykta

VerknechonskUvat

Bolshekhetsky

Underpinning the future

•

The four promises made in February 2003:

−

Production Growth

−

Technology Transfer

−

Corporate Governance

−

Good Corporate Citizen of Russia

•

Organisational Capability –

building a world-class company

Tony Hayward

Group Chief Executive Designate

E&P investment: 2004 –

2007

2006 Capex excludes RosneftBP projection for 2007TNK-BP and PAE are self-funding

0

2

4

6

8

10

12

14

16

2004 2005 2006 2007e

Organic Capex$bn

BP TNK-BP Pan American Energy

Margin pressures

•

Inflationary pressure on operating costs partly mitigated by

−

Supply chain management

−

Focussing activity on the most material opportunities

•

Government take increasing

•

Rising depreciation per barrel

Portfolio evolution

mmboed

EPC 2

NPC 2

TNK-BP 2Disposals 1

0

0.5

1.0

1.5

2.0

2.5

3.0

3.5

4.0

4.5

2001 2002 2003 2004 2005 2006

1

Reported production associated with assets divested between 2001

and 2006 inclusive2

Retained -

1/1/07 Portfolio

Production outlook

Guidance impacted by:

•

Focus on safety and operational efficiency

•

PSC entitlements -$40/bbl to $60/bbl price assumption

•

2006 divestments

•

Gulf of Mexico project delays

•

TNK-BP project phasing

•

Conservatism −

Greater allowance for unplanned downtime

−

Operational efficiency−

Unexpected events

−

Activity deferred to increase value

Production guidance

Guidance based on current portfolio at $60/barrel:

2007

3.8 -3.9 mmboedEffectively flat vs

2006 after allowing for

divestment impact

By 2009

More than 4.0 mmboed

By 2012


Reserve base strong : portfolio lengthening : sustainable growth

BP estimates for 2007, 2009 and 2012

Resource growth & progression 2002 –

2006

Non-proved

Proved

12.1

New

discoveries

2.4

7.0 Produced

8.37.2

Further

appraisal, revisions

PurchasedStart ‘02

resources

26.2

16.3

42.5

Sold

4.5

2.0

End ‘06 resources

41.3

17.7

59.0

8.0

Totals in billion boeProved reserves SEC basis

The ultimate prize: improving recovery

•

Recovery to date:

19%

•

Proved reserves:

28%

−

12 years of current production

•

Today’s non-proved recovery limit: 49%

−

Additional 29 years of current production

•

The future:

1% improvement = 2 billion boe

E&P –

a sustainable future

•

Focussed and successful exploration and access strategy

•

13 year track record of 100%+ reserves replacement continues*

•

Sustainable growth−


by 2012

•

Strong and growing resource base

•

Challenges : Alaska and North Sea operational performance, major project delays, margin pressure as a result of cost inflation, rising depreciation and government take

•

Response: Discipline, focus & technology

* SEC basis, 5 year moving averageBP estimates for 2012

John Manzoni

Chief Executive, Refining & Marketing

R&M: Key messages

•

Focus on safety and integrity

•

Improvement from 2006

•

Disciplined execution of strategy

Baker Panel

•

Implement panel recommendations

•

Recommendations in line with actions already underway; more to do

•

BP committed to becoming an industry leader in process safety

•

Integrity spend in US refineries increased from $1.2bn (2005) to $1.7bn per year (2007-10)

BP estimates for 2007-2010

Refining: Texas City

Throughputkbpd %

0

100

200

300

400

500

2005 2006 2007e 2008e0

20

40

60

80

100

Sweet Sour High value products


Refining: Availability

Availability%

50

60

70

80

90

100

2004 2005 2006 2007e 2008e


Refining: Portfolio

Average Size kbpd

Complexity index

CVX

RDS

XOM

COP

Total

BP

120

140

160

180

200

220

240

7.0 8.0 9.0 10.0 11.0

Circle area proportional to nameplate capacity

2 mmbbl/d

Source: Oil & Gas Journal 2006Excludes TNK-BP

Marketing: Strategy unchanged

•

Differentiated branded offers and disciplined execution to grow gross margin

•

Focused investment in markets where we can be number 1 or 2

•

Cost management to ensure efficiency improves over time

Marketing: Cost efficiency

•

On track to deliver $0.5bn cost benefits in 2008 from efficiency projects

•

Further productivity improvements to come from investments into systems

Gross Margin / Distribution and admin costs

1.2

1.3

1.4

2005 2006 2007e

Headcount reduction

0

1000

2000

3000

2005 2006 2007e

BP estimates for 2007 and 2008

R&M: Investment patternsOrganic capex

$bn

Disposals

2004 –

2006

average

(2)

(1)

0

1

2

3

4

5Marketing

Biofuels

Infrastructure

Aromatics & Acetyls

Refining

Disposals

2007e

BP estimates for 2007

R&M: Key messages

•

Focus on safety and integrity

•

Improvement from 2006

•

Disciplined execution of strategy

John Browne


Gas, Power & Renewables

•

Gas remains an important part of the portfolio

•

Growing LNG marketing and trading business

•

Second largest gas producers among IOCs

•

World’s largest marketer and trader among IOCs

•

Wind capacity 450 MW by end 2007

•

Solar capacity 300 MW by end 2007

BP estimates for 2007

10.1

2.8

1.0

13.9

2005

12.1*

3.1

0.7

15.9*

2006

~13

~4

~1

Exploration & Production

Refining & Marketing

Gas, Power, Renewables & Other

~18Capital expenditure

2007e$bn

Investment

Organic capex only*Excludes $1bn investment in Rosneft

IPOBP estimates for 2007

Historical dividend

2001-2006Average

1987-2006Average

0%

2%

4%

6%

8%

10%

12%

14%

DollarDPS

Inflation SterlingDPS

Inflation

CAGR

0%

2%

4%

6%

8%

10%

12%

14%

DollarDPS

Inflation SterlingDPS

Inflation

CAGR

Dividends as paid basis

Impact of share buyback programme 2006 vs. 2001

2915Production

7959Dividend

8061Cash from operations

195163Replacement cost profit

Per-share growth(%)

Absolute growth(%)

2007 guidance

•

Production

-

3.8 –

3.9 mmboed assuming $60/bbl oil price and current portfolio

•

Organic capex

-

Around $18bn

•

Total Group costs

-

Expected to grow in line with sector inflation

•

Distribution policy unchanged

-

Distribute 100% of all excess free cash flow to shareholders

BP estimates

Summary

•

Priorities: safety and performance

•

High-quality asset base

•

Acting on lessons learned from 2005-06

•

Robust and unchanged financial framework

Questions & answers

John Browne Group Chief Executive

Byron Grote Chief Financial Officer

Tony Hayward Group Chief Executive Designate

Bob Dudley Chief Executive Officer TNK-BP

John Manzoni Chief Executive R&M

Vivienne Cox Chief Executive GP&R

Bob Malone Chairman & President, BP America Inc.

David Allen Group Managing Director & Chief of Staff

Iain Conn Group Managing Director

Andy Inglis Chief Executive E&P

London New York

bp full year 2006 results and strategy update · 2007-02-06 · 2006: financial results •...

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